Gullet mandrel
The present disclosure provides a gullet mandrel for fluid flow optimization in a wellbore. The gullet mandrel may be coupled to a downhole valve, such that a tubing string in a wellbore will have a plurality of valves coupled to a plurality of mandrels. Each gullet mandrel may have a valve recess and one or more gullets (or grooves) located in an exterior portion of the mandrel body. The gullets may have a wide variety of configurations, and may be formed in a portion, a majority, or substantially all of the mandrel. The gullets may direct movement of fluid exterior to the tubing string and help force fluid into a laminar or linear flow pattern and prevent the formation of slug flows and/or lessen the problems encountered by slug flows. The disclosed gullet mandrel may be used in any fluid injection or production operation, such as gas-lift operations.
Latest Oracle Downhole Services Ltd. Patents:
This application claims priority to U.S. provisional patent application No. 62/934,951, filed on Nov. 13, 2020, the entire content of which is incorporated herein by reference.
BACKGROUND OF THE INVENTION Field of the InventionThe present invention relates to a system and apparatus for the production or injection of fluids from a wellbore, and particular for a downhole mandrel utilized in gas-lift operations, enhanced oil recovery (EOR) operations, and carbon dioxide (CO2) sequestration.
Description of the Related ArtIn the oil and gas industry, downhole valves are used as part of a tubing string to permit fluid communication between the formation or reservoir through which a wellbore intersects. Such valves may be used to produce fluids into the tubing string, which may be lifted to the surface using natural reservoir pressure or artificial lift solutions. Downhole valves may also be used to inject fluids into the wellbore or the annulus between the well casing and production tubing. Injected fluids can include chemicals to enhance oil recovery or stimulation fluids such as demulsifiers, corrosion inhibitors, scale inhibitors, or paraffin inhibitors. The various chemicals and their intended effects are well known in the industry.
Mechanically actuating downhole valves and controlling them to control their opening and closing are non-trivial issues, and many different solutions have been proposed and implemented in the art. Potential solutions must accommodate harsh downhole conditions, dimensional limitations imposed by tubing size, and other known difficulties. In general, conventional downhole valves are based on hydraulics and do not use control sensors to drive the position of the valve inlet/outlet; conventional valves are partially (or fully) opened or closed by hydraulic control lines from the downhole valve and the surface. Conventional valves present numerous problems. For example, a conventional hydraulic valve requires a separate control line from the wellhead to each downhole valve, which practically limits the number of downhole valves possible. Another problem includes complicated wellhead exits due to the number of control lines used in a well. Further, deep wells require increased surface pressure to actuate downhole valves, which becomes a safety hazard. Still further, if one return line is used for all downhole valves, if it fails, all the lines fail and/or all downhole valves are rendered inoperable.
There are existing technologies that relate to a downhole valve. See, e.g., U.S. Pat. Nos. 8,555,956; 8,776,896; 9,903,182; 9,970,262; 10,066,467; 10,280,708; and U.S. Patent Publication No. 2018/0171751, incorporated herein by reference. As another example, Schlumberger offers a production system named Manara. The Manara system utilizes a single control line that connects multiple downhole valves. However, the Manara product uses wellbore pressure to actuate the control valve, which is large and expensive.
A mandrel is generally known in the art as a bar, shaft, or spindle around which other components are arranged or assembled. For the purposes of this disclosure, it may also refer to specialized tubular components that are key parts of an assembly or system, such as a fracturing mandrel, a gas-lift mandrel, or a packer mandrel. A gas-lift mandrel is known in the art as a component assembled with the production tubing string to provide a way to locate and/or place valves used in an artificial gas lift operation. In some embodiments, a port in the gas-lift mandrel provides communication between the tubing annulus and the tubing interior passageway. A conventional mandrel is substantially cylindrical and/or tubular, such that a cross-sectional view of the mandrel may look like a circle. A tubing sub may also be considered a mandrel.
A need exists for an improved downhole valve and mandrel system and connection thereof. A need exists for an improved mandrel. A need exists for a connection coupling for a downhole valve to a mandrel. A need exists for an improved mandrel to efficiently and effectively couple a downhole valve to a tubing string. A need exists for an improved mandrel that stabilizes and/or assists fluid flow in a downhole application. A need exists for an improved apparatus and system for directing and/or controlling fluid in an annulus of a tubing string during production or injection operations.
SUMMARY OF THE INVENTIONThe present disclosure provides a gullet mandrel for fluid flow optimization in a wellbore. The gullet mandrel may be coupled to a downhole valve, such that a tubing string in a wellbore will have a plurality of valves coupled to a plurality of mandrels. Each gullet mandrel may have a valve recess and one or more gullets (or grooves) located in an exterior portion of the mandrel body. The gullets may have a wide variety of configurations, and may be formed in a portion, a majority, or substantially all of the mandrel. The gullets may direct movement of fluid exterior to the tubing string and help force fluid into a laminar or linear flow pattern and prevent the formation of slug flows and/or lessen the problems encountered by slug flows. The disclosed gullet mandrel may be used in any fluid injection or production operation, such as gas-lift operations.
Disclosed is a downhole mandrel that comprises a body, a main passage within the body, and a plurality of gullets located in an exterior portion of the body. The mandrel may be configured to couple with a tubing string, wherein the main passage is fluidly coupled to a main passage of the tubing string. The mandrel may be a gas lift mandrel or one that is used for artificial lift applications. The main passage may be located substantially in a center of the body or off center within the body. The plurality of gullets may be configured to direct fluid in an annulus of a wellbore into linear flow and/or to prevent slug flow. The plurality of gullets may be configured to assist fluid flow movement in an annulus of a downhole well.
The plurality of gullets may be longitudinally positioned along a substantial length of the body. The plurality of gullets may comprise two, three, four, or more gullets. Each of the plurality of gullets may have substantially the same shape or size, or may have different configurations. The plurality of gullets may comprise one or more gullets with a first configuration and one or more gullets with a second configuration. Likewise, the plurality of gullets may comprise a first plurality of gullets with a first configuration and a second plurality of gullets with a second configuration. Each of the plurality of gullets may comprise a groove, which may be substantially arcuate, circular, cylindrical, triangular, or any other shapes. The plurality of gullets may be located symmetrically around the mandrel. The plurality of gullets may be helically arranged around the mandrel or arranged in a spiral around the mandrel. The plurality of gullets may be arranged in substantially straight lines around the mandrel. The mandrel may comprise a protrusion of the body located between each of the plurality of gullets.
The mandrel may comprise a channel that runs longitudinally along a substantial length of the body. The channel may be configured to receive a valve assembly. The mandrel may comprise a valve assembly positioned in a valve recess of the mandrel. The mandrel may comprise a shroud coupled to the body, such that the shroud protects any valve assembly and electronics while not substantially covering the plurality of gullets. The mandrel may comprise a shroud and a plurality of securing brackets that couple a valve to the body, wherein the shroud substantially covers the plurality of securing brackets.
Also disclosed is a downhole mandrel that comprises a body and one or more gullets located in an exterior portion of the body. The one or more gullets may comprise a plurality of gullets that run longitudinally along a substantial length of the body.
Also disclosed is a downhole valve system that comprises a plurality of mandrels coupled to a tubing string and a downhole valve coupled to each of the plurality of mandrels, wherein each of the plurality of mandrels comprises a plurality of gullets located in an exterior portion of the mandrel. Each of the plurality of mandrels may have the same shape. Each of the plurality of mandrels may have the same configuration of gullets. A bottom most of the plurality of mandrels may comprise a first gullet configuration and the remaining plurality of mandrels may comprise a second gullet configuration. A bottom most of the plurality of mandrels may comprise a plurality of spiral gullets and the remaining plurality of mandrels may comprise a plurality of substantially straight gullets. At least one of one of the plurality of mandrels comprises a shroud, while in other embodiments a majority or substantially all of the mandrels may comprise a shroud.
The following drawings form part of the present specification and are included to further demonstrate certain aspects of the present invention. The invention may be better understood by reference to one or more of these drawings in combination with the detailed description of specific embodiments presented herein.
Various features and advantageous details are explained more fully with reference to the nonlimiting embodiments that are illustrated in the accompanying drawings and detailed in the following description. Descriptions of well-known starting materials, processing techniques, components, and equipment are omitted so as not to unnecessarily obscure the invention in detail. It should be understood, however, that the detailed description and the specific examples, while indicating embodiments of the invention, are given by way of illustration only, and not by way of limitation. Various substitutions, modifications, additions, and/or rearrangements within the spirit and/or scope of the underlying inventive concept will become apparent to those skilled in the art from this disclosure. The following detailed description does not limit the invention.
Reference throughout the specification to “one embodiment” or “an embodiment” means that a particular feature, structure, or characteristic described in connection with an embodiment is included in at least one embodiment of the subject matter disclosed. Thus, the appearance of the phrases “in one embodiment” or “in an embodiment” in various places throughout the specification is not necessarily referring to the same embodiment. Further, the particular features, structures, or characteristics may be combined in any suitable manner in one or more embodiments.
As used herein, longitudinal or “axial” means aligned with the long axis of tubular elements associated with the disclosure, and transverse means a direction that is substantially perpendicular to the longitudinal direction. As used herein, uphole and downhole are used to describe relative longitudinal positions of parts in the well bore. One of skill in the art will recognize that wellbores may not be strictly vertical or horizontal, and may be slanted or curved in various configurations. Therefore, the longitudinal direction may or may not be vertical (i.e., perpendicular to the plane of the horizon), and the transverse direction may or may not be horizontal (i.e., parallel to the plane of the horizon). Further, an uphole part may or may not be disposed above a downhole part. As used herein, tubing string may refer to any tubular structure in a wellbore that may be used to convey fluid in a wellbore. Non-limiting examples of tubing string include rigid pipe segments, and coiled tubing.
Overview
The content of U.S. Patent Publication No. 2019/0316440 (“the '440 Patent Publication”), entitled Downhole Valve for Production or Injection, is incorporated herein by reference.
Disclosed is a mandrel with one or more gullets located in an exterior portion of the mandrel body. The gullet mandrel may be coupled to a downhole valve, such that a tubing string in a wellbore will have a plurality of downhole valves coupled to a plurality of mandrels. The gullet mandrel may have a shroud or other covering over an exterior portion of the mandrel that protects the valve and other external components installed within the mandrel. Each gullet mandrel may have a valve recess and one or more gullets (or grooves) located in an exterior portion of the mandrel body. The gullets may have a wide variety of configurations, and may be formed around a portion, a majority, or substantially all of the exterior body of the mandrel. The gullets may be any configuration, such as any size or shape, and may be circular or non-circular, triangular, rectangular, etc. The gullets may be axially located around the mandrel and may be helical, spiral, or straight gullets positioned around the mandrel. The gullets direct movement of fluid exterior to the tubing string and help force fluid into a laminar or linear flow pattern and prevent the formation of slug flows and/or lessen the problems encountered by slug flows. The disclosed gullet mandrel may be used in any fluid injection or production operation, such as gas-lift and enhanced oil recovery operations and carbon dioxide sequestration.
Valve
In one embodiment, the utilized downhole valve assembly may be the same or similar to the valve described in U.S. Patent Publication No. 2019/0316440 (“the '440 Patent Publication”), which is incorporated herein by reference. However, one of skill in the art will recognize that this invention is not necessarily limited to such a valve, and other valves may similarly be used with the disclosed processes and methods described herein.
In one embodiment, valve assembly 14 may be electronically coupled to other downhole equipment and the surface via electric cable 40. Electric cable 40 may be any downhole instrumentation cable, such as tubing encapsulated cable (TEC), and may transmit data and/or power between various downhole devices, such as a plurality of downhole valve assemblies and/or sensors. In one embodiment, cable 40 is a 4 conductor, ¼″ TE cable that allows data communication between downhole equipment (tools, sensors, etc.) and the surface. Cable 40 may be directly or indirectly coupled to valve assembly 14, such as by induction means or wet or dry electrical connectors. In one embodiment, valve assembly may also comprise one or more sensors 44 to monitor various conditions downhole. Sensor 44 may be located within or adjacent to the valve assembly. In one embodiment, electrical cable 40 is directly coupled to a control circuit within the valve assembly, which is then directly coupled to one or more sensors 44. In one embodiment, sensor 44 may comprise a wide variety of sensors as is known in the art, such as temperature, pressure, acoustic, and flow rate. In another embodiment, cable 40 may also comprise sensors 42 (exterior to the valve assembly) to monitor various conditions downhole. Valuable data may be collected and read from the surface, in real-time or near real-time, by the telemetry sensors and/or cable 40.
As described herein, one embodiment of the disclosed valve assembly is coupled to a tubing sub (or mandrel) that is substantially in-line with a tubing string. The tubing string may be located in a horizontal, vertical, or lateral well. Further, the disclosed valve assembly can be attached to a tubing string, production liner, slotted liner, coiled tubing, and even surface lines. In other words, the disclosed valve assembly may be coupled to a wide variety of tubulars, fluid passageways, or fluid containing devices to control fluid flow in and out of the relevant device. Still further, while one embodiment of the disclosed valve assembly is located downhole, the valve assembly disclosed herein is not limited to downhole applications and in some embodiments may be used in surface applications.
As illustrated in
As illustrated in
In one embodiment, valve section 220 comprises lateral port 224 that opens into valve chamber 229 and axial port 222 that opens into valve chamber 229. In one embodiment, port 222 is considered the main valve passage and/or exterior opening because it is in fluid communication with the exterior portion of the tubing string, such as fluids existing in the annulus of the borehole. In one embodiment, lateral port 224 may align with valve opening 12 (see
In one embodiment, valve section 220 comprises valve plug 221 that is coupled to power section 230 via drivetrain 234. In one embodiment, valve plug 221 may have any number of configurations, such as a dart, flat face, stepped body, or knife. In one embodiment, plug 221 is an elongated dart with head 225, tail 227, and side 223. Plug 221 may be positioned within cylindrical valve chamber 229. In one embodiment, plug 221 is configured to seal against lateral port 224 and/or axial port 222. For example, a lower end of valve chamber 229 may have a valve seat 228 (see
In one embodiment, valve plug 221 is moveable between a substantially closed position (see, e.g.,
Valve plug 221 may be moved by rotation and/or linear movement of the valve plug. In one embodiment, valve plug 221 is coupled to drive shaft 234 which is coupled to motor 232. In one embodiment, the valve plug may be moved axially based on linear or rotational movement of the motor and/or drive shaft. In one embodiment, the valve plug may comprise a worm gear, ball screw, direct drive torque motor, or linear DC servo motor, each which is available to those of skill in the art. In one embodiment, drive shaft 234 extends through power section 230 and connects to motor 232. Thus, motor 232 is operatively coupled to valve plug 221 via drive shaft 234. In one embodiment, motor 232 rotates drive shaft 234 which subsequently rotates valve plug 221. In one embodiment, motor 232 is a reversible DC motor as is known in the art
Electronics section 240 may comprise motor controller 246 and various sensors 244, such as telemetry, valve position, and electric sensors. In one embodiment, motor controller 246 is a conventional controller known to those of skill in the art and it is operatively coupled to motor 232. Controller 246 may be electrically controlled from the surface via cable 40. Controller 246 allows fine control over the motor.
As is known in the art, communication to downhole components over a long distance is problematic with any telemetry-based technology. In other words, signals from a power supply and/or remote location over a long length provide numerous issues, such as signal conditioning. Necessary software and user interface (UI) may be necessary, as is known in the art, to push power (TX) and receive data (RX) from a downhole valve to the surface at distances over 5000 km. The present disclosure allows real-time data communications and/or power to be transmitted to a plurality of downhole valves via a single electrical cable over distances over 5000 km and avoids numerous signal conditioning issues existing in the prior art. Using the appropriate user interfaces, the downhole valves and valve positions may be controlled from the surface or any other remote location. For example, any remote location can query the sensors for data and diagnostics for each valve. Further, the necessary control system and software allow for automation and control of the valves and valve positions based on real-time downhole conditions.
In one embodiment, downhole valve system 300 comprises a valve assembly coupled to an offset tubing sub. For example, as illustrated in
Valve assembly 350 may be coupled to tubing sub 310 in any number of arrangements and by a variety of attachment mechanisms. In one embodiment, tubing sub 310 comprises trough or channel 311 that runs parallel to a long axis of the tubing sub. Trough 311 (or channel) is configured to receive valve assembly 350 within the channel and to couple the valve assembly to the tubing sub and/or tubing string. Electrical cable 40 and various sensors may also be positioned within the channel and/or adjacent to the valve assembly when coupled to the tubing sub. On either side of the trough may be located recesses 316 which allows one or more attachment devices to securely couple the valve assembly to the tubing sub and within the channel. As illustrated in
The disclosed valve is well suited for small to large diameter tubing and annular spaces. In one embodiment, the unique configuration of the tubing sub, valve assembly, and coupling means between the tubing sub and valve assembly allow use of the valve assembly in small spaces, such as a 2⅜″ diameter tubing in 4″ casing (or even smaller). This compact configuration is substantially better than conventional valve designs. As one example, the disclosed valve assembly configuration does not affect the internals of the tubing string. For example, as compared to conventional valve technologies, the disclosed valve does not affect the internal diameter of the tubing, and thus may be used for smaller diameter pipe than traditionally possible. Of course, the valve can be scaled up for additional pipe sizes, such as up to 7″ ID. However, in general, the disclosed valve may be used with any size tubing and casing.
As illustrated in
As illustrated in
As illustrated in
Gullet Mandrel
The present disclosure provides an improved mandrel (and/or tubing sub) used to couple a downhole valve to a tubing string. In one embodiment, the coupled valve assembly may be the same or similar to the valve assembly described herein, but the invention is not limited to such a vale. In other embodiments, any type of downhole valve or downhole component may be coupled to the disclosed gullet mandrel and obtain the benefits described herein. While a gullet mandrel as disclosed herein is more difficult and costlier to manufacture, it provides superior operational benefits for wellbore operations, particularly for artificial gas-lift operations.
As illustrated in
In one embodiment, tubing sub 300 illustrated in
Trough or valve recess 420 may be located on one side of the mandrel and be configured to receive valve 421 and in some embodiments associated cable 423. While recess 420 is shown as rectangular in
Referring to
Between each of the pairs of gullets is located a protrusion or tooth, much like a saw tooth between concave portions (e.g., gullets) of a saw blade. In one embodiment the protrusions form part of the cylindrical exterior body of the mandrel. For example, tooth/protrusion 443 is located between gullet 431 and gullet 433, while tooth/protrusion 447 is located between gullet 435 and gullet 437. Depending on the configuration of the gullets, a larger protrusion may be located between some of the gullets, such as protrusion 445. Likewise, a larger protrusion and/or different protrusion may be located between the gullets and valve recess 420. For example, protrusion 449 is located between gullet 437 and valve recess 420, while protrusion 441 is located between gullet 41 and valve recess 420. In the embodiment illustrated in
In one embodiment, gullets 431, 433, 435, and 437 are each substantially the same shape and size. For example, each of these gullets may be substantially cylindrical, and may be approximately between 0.5″ and 2.0″ in diameter, and more particularly about 1.0″ in diameter. In general, the configuration of the gullets may be completely variable based on the valve dimensions, the mandrel dimensions, and the type of completion and/or application of the downhole valves and mandrel. In other embodiments, two of the gullets may have a first size and shape (such as gullets 431 and 437), and two of the gullets may have a second size and shape (such as gullets 433 and 435). Such an embodiment of different sized gullets allows the maximum amount of material to be removed from the body of mandrel while still maintaining sufficient strength at particular areas, such as the boundary near main passageway 403. One of skill in the art will realize that a mandrel is not a two-dimensional object and any gullets formed in the mandrel will have a three-dimensional aspect and will extend partially, a majority of, or substantially all of the length of the mandrel. The gullets may be machined throughout the external cavity of the mandrel in any length and configuration depending on production limitations and/or gas lift supply requirements.
In downhole conditions, the valve, control line, and other equipment coupled to a mandrel may be exposed to harsh conditions in the wellbore. Similarly, if the downhole valve and mandrel is utilized in open hole conditions (such as in the ocean), the mandrel may be subject to external forces (e.g., moving objects, debris, etc.) hitting the mandrel in addition to harsh conditions. To protect the mandrel, the equipment coupled to the mandrel, and/or the connections of the mandrel to the tubing, a shroud or other protective covering may be coupled to an exterior portion of the mandrel. Such an embodiment is illustrated in
Referring to
Referring to
Referring to
In one embodiment, the gullet mandrel is specifically designed to help slow down turbulent flow for fluid flowing in an annulus of the tubing string (e.g., the portion between the wellbore wall and the tubing string/pipe). In one embodiment, the gullets may be configured to facilitate linear flow of the fluid and to prevent slug flow and other undesirable fluid flow situations. In one embodiment, a benefit of the gullet mandrel is to minimize the mass of the mandrel by removing portions of the mandrel that are not useful or needed during use of the mandrel and/or operation of the valve within the mandrel. As much mass may be removed from the exterior portion of the mandrel body while still maintaining structural integrity of the mandrel and its ability to withstand force, pressure, and other stressful situations. In one embodiment, as large a groove as possible is made to keep the remaining mandrel portions to withstand at least 5000 psi, and in some embodiments up to 10,000 psi. One of skill in the art will realize that other pressures may be specifically designed based on the particular application of the mandrel. In one embodiment, the gullet can be made as close as 0.25″ inches from an interior passageway of the mandrel.
The gullets may be formed by a variety of procedures as is known in in the art. In one embodiment, the gullets are machined out of a cylindrical metal piece. The gullets may be formed before or after the primary passageway (see, e.g., element 403 in
In one embodiment, the mandrel is approximately 3½″ in diameter and is coupled to a tubing string with a pipe diameter of approximately 4½″ in diameter. The mandrel may be greater or less than a diameter of the tubing string. In one embodiment, the mandrel may be coupled to any tubular used in a wellbore environment. In one embodiment, the downhole tubular comprises jointed tubing, such as any standard tubing sizes of 2⅜″, 2⅞″, 3½″, etc. The inner diameter of the mandrel increases based on the size of the tubing selected; likewise, the outer diameter of the mandrel is sized according to the production tubing that it resides within (such as 4½″, 5½″, 6½″, etc. In other embodiments, the downhole tubular comprises production lining or slotted lining.
All of the methods disclosed and claimed herein can be made and executed without undue experimentation in light of the present disclosure. While the apparatus and methods of this invention have been described in terms of preferred embodiments, it will be apparent to those of skill in the art that variations may be applied to the methods and in the steps or in the sequence of steps of the method described herein without departing from the concept, spirit and scope of the invention. In addition, modifications may be made to the disclosed apparatus and components may be eliminated or substituted for the components described herein where the same or similar results would be achieved. All such similar substitutes and modifications apparent to those skilled in the art are deemed to be within the spirit, scope, and concept of the invention.
Many other variations in the system are within the scope of the invention. For example, the mandrel may be used in any downhole application for fluid production or injection and is not limited to artificial lift applications. For example, it may be used in artificial lift, gas lift, and/or enhanced oil recovery operations, as well as carbon dioxide sequestration. As another example, the disclosed gullet mandrel may have any number or configuration of grooves. For example, two, three, or four or more grooves may be located in an exterior portion of the mandrel. The groove may be any shape, whether circular, non-circular, triangular, rectangular, etc. The grooves may be axially located around the mandrel and may be helical, spiral, or straight grooves. In one embodiment the grooves are located along a substantial longitudinal portion of the mandrel, while in other embodiments only part of the mandrel may have the grooves. Any number of securing brackets may be utilized (such as between one to four or more brackets). A shroud or protective covering may be coupled to the mandrel to protect the securing brackets and enclosed valve and electronic equipment. It is emphasized that the foregoing embodiments are only examples of the very many different structural and material configurations that are possible within the scope of the present invention.
Although the invention(s) is/are described herein with reference to specific embodiments, various modifications and changes can be made without departing from the scope of the present invention(s), as presently set forth in the claims below. Accordingly, the specification and figures are to be regarded in an illustrative rather than a restrictive sense, and all such modifications are intended to be included within the scope of the present invention(s). Any benefits, advantages, or solutions to problems that are described herein with regard to specific embodiments are not intended to be construed as a critical, required, or essential feature or element of any or all the claims.
Unless stated otherwise, terms such as “first” and “second” are used to arbitrarily distinguish between the elements such terms describe. Thus, these terms are not necessarily intended to indicate temporal or other prioritization of such elements. The terms “coupled” or “operably coupled” are defined as connected, although not necessarily directly, and not necessarily mechanically. The terms “a” and “an” are defined as one or more unless stated otherwise. The terms “comprise” (and any form of comprise, such as “comprises” and “comprising”), “have” (and any form of have, such as “has” and “having”), “include” (and any form of include, such as “includes” and “including”) and “contain” (and any form of contain, such as “contains” and “containing”) are open-ended linking verbs. As a result, a system, device, or apparatus that “comprises,” “has,” “includes” or “contains” one or more elements possesses those one or more elements but is not limited to possessing only those one or more elements. Similarly, a method or process that “comprises,” “has,” “includes” or “contains” one or more operations possesses those one or more operations but is not limited to possessing only those one or more operations.
Claims
1. A downhole mandrel, comprising:
- a body;
- a main passage within the body;
- a plurality of gullets located in an exterior portion of the body; and
- a channel configured to receive a valve assembly located in an exterior portion of the body.
2. The mandrel of claim 1, wherein the plurality of gullets runs longitudinally along a substantial length of the body.
3. The mandrel of claim 1, wherein the mandrel is configured to couple with a tubing string, wherein the main passage is fluidly coupled to a main passage of the tubing string.
4. The mandrel of claim 1, wherein the plurality of gullets comprises at least three gullets.
5. The mandrel of claim 1, wherein the plurality of gullets comprises at least four gullets.
6. The mandrel of claim 1, wherein each of the plurality of gullets has substantially the same shape.
7. The mandrel of claim 1, wherein the plurality of gullets comprises one or more gullets with a first configuration and one or more gullets with a second configuration.
8. The mandrel of claim 1, wherein the plurality of gullets comprises a first plurality of gullets with a first configuration and a second plurality of gullets with a second configuration.
9. The mandrel of claim 1, further comprising a protrusion of the body located between each of the plurality of gullets.
10. The mandrel of claim 1, wherein each of the plurality of gullets comprises a groove.
11. The mandrel of claim 1, wherein each of the plurality of gullets is substantially arcuate.
12. The mandrel of claim 1, wherein at least some of the plurality of gullets is circular.
13. The mandrel of claim 1, wherein the plurality of gullets is located symmetrically around the mandrel.
14. The mandrel of claim 1, wherein the plurality of gullets is helically arranged around the mandrel.
15. The mandrel of claim 1, wherein the plurality of gullets is arranged in a spiral around the mandrel.
16. The mandrel of claim 1, wherein the plurality of gullets is arranged in substantially straight lines around the mandrel.
17. The mandrel of claim 1, wherein the channel runs longitudinally along a substantial length of the body.
18. The mandrel of claim 1, further comprising a valve assembly positioned in the channel.
19. The mandrel of claim 1, wherein the main passage is located substantially in a center of the body.
20. The mandrel of claim 1, wherein the main passage is located off center within the body.
21. The mandrel of claim 1, wherein the mandrel is a gas lift mandrel.
22. The mandrel of claim 1, wherein the plurality of gullets is configured to direct fluid in an annulus of a wellbore into linear flow.
23. The mandrel of claim 1, wherein the plurality of gullets is configured to prevent slug flow.
24. The mandrel of claim 1, wherein the plurality of gullets is configured to assist fluid flow movement in an annulus of a downhole well.
25. The mandrel of claim 1, further comprising a shroud coupled to the body.
26. The mandrel of claim 25, wherein the shroud does not substantially cover the plurality of gullets.
27. The mandrel of claim 1, further comprising a shroud, wherein the shroud substantially covers the valve assembly.
28. The mandrel of claim 1, further comprising a shroud and a plurality of securing brackets that couple the valve assembly to the body, wherein the shroud substantially covers the plurality of securing brackets.
29. A downhole valve system, comprising:
- a plurality of mandrels coupled to a tubing string; and
- a downhole valve coupled to each of the plurality of mandrels,
- wherein a bottom most of the plurality of mandrels comprises a first mandrel configuration with a plurality of gullets in an exterior portion of the mandrel and the remaining plurality of mandrels comprises a second mandrel configuration.
30. The system of claim 29, wherein the second mandrel configuration comprises mandrels with no gullets.
31. The system of claim 29, wherein the second mandrel configuration comprises a plurality of substantially straight gullets.
32. The system of claim 31, wherein the plurality of gullets of the first mandrel configuration comprises a plurality of spiral gullets.
33. The system of claim 29, wherein at least one of the plurality of mandrels comprises a shroud.
34. A downhole mandrel, comprising:
- a body;
- a main passage within the body;
- a plurality of gullets located in an exterior portion of the body;
- a valve assembly; and
- a shroud, wherein the shroud substantially covers the valve assembly.
35. The mandrel of claim 34, wherein the shroud does not substantially cover the plurality of gullets.
36. The mandrel of claim 34, further comprising a plurality of securing brackets that couple the valve assembly to the body, wherein the shroud substantially covers the plurality of securing brackets.
37. A downhole gas lift mandrel, comprising:
- a main passage within the body, wherein the main passage is located off center within the body;
- a first plurality of gullets on a first exterior side of the body; and
- a second plurality of gullets on a second exterior side of the body,
- wherein the first exterior side is opposite to the second exterior side,
- wherein the first plurality of gullets comprises the same configuration as the second plurality of gullets,
- wherein each of the first and second plurality of gullets has a first gullet with a first size and a second gullet with a second size,
- wherein each of the first and second plurality of gullets is arranged in substantially straight lines around the mandrel.
38. The mandrel of claim 37, further comprising a channel configured to receive a valve assembly located in an exterior portion of the body, wherein the channel is located on the opposite side of the off-center main passage and between the first and second plurality of gullets.
39. The mandrel of claim 38, further comprising a valve assembly positioned in the channel.
40. The mandrel of claim 39, further comprising a shroud, wherein the shroud substantially covers the valve assembly.
41. The mandrel of claim 37, wherein each of the plurality of gullets comprises a diameter of between 0.5″ and 2.0″ inches.
5273112 | December 28, 1993 | Schultz |
5937945 | August 17, 1999 | Bussear et al. |
6070608 | June 6, 2000 | Pringle |
6435282 | August 20, 2002 | Robison et al. |
6715550 | April 6, 2004 | Vinegar et al. |
6758277 | July 6, 2004 | Vinegar et al. |
6776240 | August 17, 2004 | Kenison et al. |
6951252 | October 4, 2005 | Restarick et al. |
RE39583 | April 24, 2007 | Upchurch |
7387165 | June 17, 2008 | Lopez de Cardenas et al. |
8186444 | May 29, 2012 | Patel |
8752629 | June 17, 2014 | Moen |
8905128 | December 9, 2014 | Arizmendi, Jr. et al. |
9228402 | January 5, 2016 | Strilchuk |
9228423 | January 5, 2016 | Powell et al. |
9291033 | March 22, 2016 | Scott et al. |
9316076 | April 19, 2016 | Longfield et al. |
9453389 | September 27, 2016 | Anderson et al. |
9453397 | September 27, 2016 | Dowling |
9896906 | February 20, 2018 | Tunkiel et al. |
9903182 | February 27, 2018 | Getzlaf et al. |
9970262 | May 15, 2018 | Werriers et al. |
10066467 | September 4, 2018 | Getzlaf et al. |
10280708 | May 7, 2019 | Lamb |
10323481 | June 18, 2019 | Pratt et al. |
10443344 | October 15, 2019 | Vasques et al. |
10480284 | November 19, 2019 | Watson |
20040055752 | March 25, 2004 | Restarick |
20060124310 | June 15, 2006 | Lopez de Cardenas |
20110139510 | June 16, 2011 | Declute-Melancon |
20120043092 | February 23, 2012 | Arizmendi |
20150060084 | March 5, 2015 | Moen et al. |
20160061004 | March 3, 2016 | Tunkiel et al. |
20170336811 | November 23, 2017 | Stone et al. |
20180020229 | January 18, 2018 | Chen et al. |
20180202269 | July 19, 2018 | Wensrich |
20190003284 | January 3, 2019 | Coulston |
20190085658 | March 21, 2019 | Reid |
20190235007 | August 1, 2019 | Williamson et al. |
20190316440 | October 17, 2019 | Honeker |
20190345799 | November 14, 2019 | Foster |
20200018136 | January 16, 2020 | Bowen |
20200080393 | March 12, 2020 | Gumos |
20200256134 | August 13, 2020 | Fay |
20210222522 | July 22, 2021 | Greci |
2856184 | January 2015 | CA |
2873541 | June 2015 | CA |
2906464 | March 2016 | CA |
2916168 | June 2016 | CA |
3017294 | September 2016 | CA |
2927973 | October 2016 | CA |
2948249 | May 2017 | CA |
2991729 | January 2018 | CA |
2996116 | August 2018 | CA |
2923662 | October 2018 | CA |
1234100 | February 2005 | EP |
2017204654 | November 2017 | WO |
2019148279 | August 2019 | WO |
- International Search Report and the Written Opinion of the Canadian Intellectual Property Office for PCT Patent Application No. PCT/CA2019/050439 dated Jul. 2, 2019.
Type: Grant
Filed: Nov 10, 2020
Date of Patent: Feb 28, 2023
Patent Publication Number: 20210140287
Assignee: Oracle Downhole Services Ltd. (Nisku)
Inventors: Mahlon Lisk (Nisku), Levi Honeker (Nisku)
Primary Examiner: Michael R Wills, III
Application Number: 17/094,147
International Classification: E21B 43/14 (20060101); E21B 34/08 (20060101); E21B 34/06 (20060101); E21B 43/12 (20060101);